System for communicating information between a rig location and a cpmputer network and methods using the system

ABSTRACT

A system for communicating information between a rig location and a computer network. The system includes the computer network disposed on a location remote from the rig location and a computer disposed on the rig location, wherein the computer is communicably linked to the computer network through a communication link.

CROSS-REFERENCE TO RELATED APPLICATIONS

This application claims benefit of U.S. patent application Ser. No.09/668,785 (Attorney Docket No. WEAT/0042), filed Sep. 22, 2000,entitled METHODS AND APPARATUS FOR INTERACTIVE COMMUNICATION WITHSERVICE AND SUPPORT PERSONS and U.S. patent application Ser. No.10/936,438 (Attorney Docket No. WEAT/0291P1), filed Sep. 8, 2004,entitled METHOD AND APPARATUS FOR CONTROLLING WELLBORE EQUIPMENT. Eachof the aforementioned related patent applications is herein incorporatedby reference.

BACKGROUND OF THE INVENTION

1. Field of the Invention

Embodiments of the present invention generally relate to a communicationsystem, and more particularly, to a communication system between riglocations and the command center.

2. Description of the Related Art

Complex industrial equipment can generally be found at wellsites,platforms, nuclear and fossil fuel power generating plants, oilrefineries, petroleum and chemical processing plants, and manufacturingfacilities. Because profits associated with such complex systems may runinto the millions of dollars per day, the pressure to keep the systemsoperating continuously and efficiently is often immense. As aconsequence, specialized service personnel are immediately dispatchedwhen malfunctions or failures occur within the equipment, particularlywhen such malfunction or failure has slowed or shut down a major orimportant part of an overall operation. Further, many of these complexindustrial equipment typically require periodic inspection, maintenance,and troubleshooting by service personnel.

Due to the complexity of the equipment involved, however, many servicepersonnel often face technical problems in performing the tasks at hand.Accordingly, support personnel at the command center, such as engineers,technicians, specialists, and consultants, are often called upon tointeract with the service personnel on the rig location. Suchintervention often requires the support personnel to travel to the riglocation, while the service personnel waits at the rig location untilthe support personnel arrives, which creates unnecessary delay in therepair or maintenance of the equipment.

Therefore, a need exists in the art for a method and system forcommunicating information between the command center and a rig locationthat improves the maintenance, repair and operation of equipment on therig location.

SUMMARY OF THE INVENTION

One or more embodiments of the invention are directed to a system forcommunicating information between a rig location and a computer network.The system includes the computer network disposed on a location remotefrom the rig location and a computer disposed on the rig location,wherein the computer is communicably linked to the computer networkthrough a communication link.

One or more embodiments of the invention are also directed to a methodfor communicating information between a rig location and a computernetwork disposed on a location remote from the rig location. The methodincludes sending a signal to a computer within the computer network torequest information, receiving the information from the computer withinthe computer network, and displaying the information at the riglocation.

One or more embodiments of the invention are also directed to a methodfor displaying a graph indicating pressure difference between bottomholepressure of a wellbore and formation pressure surrounding the wellbore.The method includes: receiving a bottomhole pressure inside the wellboreat a predetermined depth, comparing the bottomhole pressure with aformation pressure surrounding the wellbore at the predetermined depth,and displaying a graphical element indicating a pressure differencebetween the bottomhole pressure and the formation pressure.

One or more embodiments of the invention are also directed to a displayfor generating a graphical user interface. The display includes one ormore graphical elements. Each graphical element indicates a pressuredifference between a bottomhole pressure of a wellbore at apredetermined depth and a formation pressure surrounding the wellbore.At least one of the graphical elements represents at least one of anunderbalanced condition, a balanced condition and an overbalancedcondition.

One or more embodiments of the invention are also directed to a methodfor controlling a drilling operation. The method includes reviewing adisplay of one or more graphical elements. Each graphical elementindicates a pressure difference between a bottomhole pressure of awellbore at a predetermined depth and a formation pressure surroundingthe wellbore. The method further includes identifying a trend on thegraphical elements and generating a set of instructions based on thetrend.

BRIEF DESCRIPTION OF THE DRAWINGS

So that the manner in which the above recited features of the presentinvention can be understood in detail, a more particular description ofthe invention, briefly summarized above, may be had by reference toembodiments, some of which are illustrated in the appended drawings. Itis to be noted, however, that the appended drawings illustrate onlytypical embodiments of this invention and are therefore not to beconsidered limiting of its scope, for the invention may admit to otherequally effective embodiments.

FIG. 1 illustrates a communication system for communicating informationbetween a rig location and a computer network in accordance with one ormore embodiments of the invention.

FIG. 2 illustrates a schematic diagram of an offshore oil drillingsystem having the communication system illustrated in FIG. 1 inaccordance with one or more embodiments of the invention.

FIG. 3 illustrates a flow diagram of a method for communicating with thecommand center in accordance with one or more embodiments of theinvention.

FIG. 4 illustrates a display that indicates pressure difference betweenbottomhole pressure of a wellbore and formation pressure surrounding thewellbore in accordance with one or more embodiments of the invention.

FIG. 5 illustrates a flow diagram of a method for displaying a graphillustrating the pressure difference between bottomhole pressure of awellbore and formation pressure surrounding the wellbore in accordancewith one or more embodiments of the invention.

FIG. 6 illustrates a flow diagram of a method for controlling a drillingoperation in accordance with one or more embodiments of the invention.

DETAILED DESCRIPTION

FIG. 1 illustrates a communication system 100 for communicatinginformation between a rig location 130 and a computer network 105 inaccordance with one or more embodiments of the invention. The riglocation 130 is communicably linked to the computer network 105 througha communication network 110. The computer network 105 may be connectedto one or more other computer networks. The computer network 105 mayinclude a command center 120, which may either be on shore or off shore.The rig location 130 may also be on shore or off shore. The computernetwork 105 is disposed on a location remote from the rig location 130.Although only one rig location is illustrated, other embodiments of theinvention contemplate additional rig locations communicably linked tothe command center 120 through the communication network 110. Althoughthe communication system 100 is described with reference to its use inthe oil and gas industry, other embodiments of the invention alsocontemplate the use of the communication system 100 in other industries,such as nuclear and fossil fuel power plants, oil refineries, petroleumand chemical processing plants, metal producing plants.

The communication network 110 may be a wireless network, a fiber opticnetwork, or a satellite network. In an embodiment in which thecommunication network 110 is a satellite network, the communicationnetwork 110 may include a communications satellite, a link connectingthe command center 120 to the satellite, and another link connecting therig location 130 to the communications satellite. The communicationssatellite may be a geostationary satellite or a low earth orbitsatellite (LEOS). Other details of the communications satellite may befound in commonly assigned U.S. patent application Ser. No. 09/668,785(Attorney Docket No. WEAT/0042), filed Sep. 22, 2000, entitled METHODSAND APPARATUS FOR INTERACTIVE COMMUNICATION WITH SERVICE AND SUPPORTPERSONS, which is incorporated herein by reference.

The command center 120 may include a computer 125, which may be ageneral-purpose computer, a microprocessor, a micro-controller, or anyother known type of computer. Computer 125 may include at least onecentral processing unit (CPU), support circuits, and memory. The CPU mayinclude one or more conventionally available microprocessors. Thesupport circuits may be well known circuits that include cache, powersupplies, input/output interface circuitry and the like. The memory mayinclude random access memory, read only memory, removable disk memory,flash memory, and various combinations of these types of memory. Thememory may sometimes be referred to as main memory and may in part beused as cache memory. The memory may store an operating system andvarious software applications. The operating system maybe used to managethe operation of computer 125. Examples of the operating system includeMicrosoft Windows, UNIX, Apple OS X, and the like.

The computer 125 may be connected to a database 128 for storinginformation, such as desired information pertaining to various tools,machines and components used on the rig location 130 and instructionalinformation for operating those tools, machines and components. Suchdesired information may include schematic diagrams, critical dimensions,calibration measurements, weights, shapes, parts checklists, and anyother information that may be useful to a service personnel using thevarious tools, machines or components on the rig location 130.Instructional information may include images and video clipsillustrating the operation of the tools, machines or components. Otherdetails of desired information and instructional information may befound in commonly assigned U.S. patent application Ser. No. 09/668,785(Attorney Docket No. WEAT/0042), filed Sep. 22, 2000, entitled METHODSAND APPARATUS FOR INTERACTIVE COMMUNICATION WITH SERVICE AND SUPPORTPERSONS, which is incorporated herein by reference.

The computer network 105 may further include a plurality of servicecomputers 109 a, 109 b and 109 c connected to the computer 125. Althoughthree service computers are shown, any number may be used, and eachservice computer may be located at a different geographic location. Thecomputer 125 may be connected to the service computers 109 a, 109 b, and109 c through a communication network 106, which may include theInternet or Intranet. Service personnel (not shown) may access thesystem 100 via any one of the service computers 109 a, 109 b, and 109 c.Like the computer 125, each service computer 109 may be ageneral-purpose computer, a microprocessor, a micro-controller, or anyother known type of computer. Each service computer 109 may include atleast one central processing unit (CPU), support circuits, and memory.The CPU may include one or more conventionally availablemicroprocessors. The support circuits may be well known circuits thatinclude cache, power supplies, input/output interface circuitry and thelike. The memory may include random access memory, read only memory,removable disk memory, flash memory, and various combinations of thesetypes of memory. The memory may store an operating system and varioussoftware applications.

The rig location 130 may include a computer 140, which is generallyconfigured to control various operations on the rig location 130. Thecomputer 140 may be a general-purpose computer, a microprocessor, amicro-controller, or any other known type of computer. The computer 140may include at least one central processing unit (CPU), supportcircuits, and memory. The CPU may include one or more conventionallyavailable microprocessors. The support circuits may be well knowncircuits that include cache, power supplies, input/output interfacecircuitry and the like. The memory may include random access memory,read only memory, removable disk memory, flash memory, and variouscombinations of these types of memory. The memory may sometimes bereferred to as main memory and may in part be used as cache memory. Thememory may store an operating system and various software applications.

The computer 140 is connected to a portable computer, such as a handheldcomputer or personal digital assistant (“PDA”) 160. The computer 140 isconnected to the PDA 160 through a wireless communication network, suchas Bluetooth or WiFi. The computer 140 may be connected to the computer125 at the command center 120 through the communication network 110. Inone embodiment, the PDA 160 is connected to the computer 125 at thecommand center 120 through the communication network 110. In anotherembodiment, the PDA 160 is connected to the computer 125 through thecomputer 140. A PDA 160 is generally a handheld device that combinescomputing, telephone/fax, Internet and networking features. A typicalPDA 160 can function as a cellular phone, fax sender, Web browser andpersonal organizer. In one embodiment, the PDA 160 is intrinsicallysafe, e.g., explosion proof.

The PDA 160 may be connected to a camera 150, a heads up display 170 andone or more sensors 180. The camera 150 may be a conventional analogcamera or a digital camera. The camera 150 may have the capability ofcapturing video information. The camera 150 may be used to capture animage or a video of a part, tool or machine in question. In oneembodiment, the PDA 160 may include the camera 150. The heads up display170 provides a hands free access to information, including images andthe Internet. The heads up display 170 may also include an audio devicefor listening to audio information. The camera 150 and the heads updisplay 170 may be attached to a hard hat using an attaching means, suchas a removable clip, epoxy, fastener, adhesive, or VELCRO™ fabric. Otherdetails of the hard hat may be found in commonly assigned U.S. patentapplication Ser. No. 09/668,785 (Attorney Docket No. WEAT/0042), filedSep. 22, 2000, entitled METHODS AND APPARATUS FOR INTERACTIVECOMMUNICATION WITH SERVICE AND SUPPORT PERSONS, which is incorporatedherein by reference.

In one embodiment, the PDA 160, the camera 150 and the heads up display170 may be used as part of a wireless video conference equipment. Assuch, the communication system 100 may be used to provide real timecommunication between the service personnel on the rig location 130 andthe support personnel at the command center 120.

The sensors 180 are configured to capture temperature, pressure, flow,torque and turn information. As such, each sensor 180 may be a pressuresensor, a temperature sensor or a flow meter. In one embodiment, thesensors 180 are connected to the PDA 160 through a wireless transceiver175. The camera 150, the heads up display 170 and the sensors 180 maycommunicate with the PDA 160 through a wireless network, such asBluetooth or WiFi. In one embodiment, the camera 150, the heads updisplay 170 and the sensors 180 may communicate with the PDA 160 throughthe computer 140.

FIG. 2 illustrates a schematic diagram of an offshore oil drillingsystem 200 having the communication system 100 in accordance with one ormore embodiments of the invention. Each well platform 260 is typicallyassociated with a plurality of well pipes that extend from the platformthrough water to the ocean floor and then downwardly into formationsunder the ocean floor. Although the invention is illustrated in relationto offshore platforms, other embodiments of the invention contemplatethat the invention could also be utilized with land based wells.

Each platform 212 is typically associated with a plurality of wells 214,wherein each well 214 is divided into a plurality of separate productionzones 216. Each production zone isolates specific areas of a well forpurposes of producing selected fluids, preventing blowouts, and avoidingwater intake. Such zones 216 may be positioned in a single verticalwell, or result when portions of different wells are located in a commonregion. The oilfield depicted in FIG. 2 includes features of wellproduction such as the drilling and completion of lateral or branchwells that extend from a particular primary wellbore. These lateral orbranch wells can be completed such that each lateral well constitutes aseparable production zone and can be isolated for selected production.Each well 214 can include a plurality of production zones 216 that aremonitored and/or controlled for efficient production and management ofthe well fluids.

FIG. 3 illustrates a flow diagram of a method 300 for communicating withthe command center 120 in accordance with one or more embodiments of theinvention. At step 310, a signal is sent to the computer 125 at thecommand center 120. In one embodiment, the signal is sent by a servicepersonnel on the rig location 130 through the computer 140. The signalmay include a request for information regarding a particular tool, partor machine on the rig location 130. The signal may be textual, audio, orvideo. For example, the service personnel may have a question regardinga particular tool during an underbalanced drilling operation. As such,the service personnel may transmit his question or request forinformation to the support personnel at the command center 120 through atext signal using the PDA 160 or through an audio signal using the audiodevice of the heads up display 170. The service personnel may also sendan image or a video to the command center 120 through the use of thecamera 150. For instance, the service personnel may capture an image ofa part or a machine that is in question and send that image to thecomputer 125 at the command center.

At step 320, the information requested at step 310 is received. Theinformation may include audio, video or text, such as an assemblydrawing of a part or machine, critical dimensions of the part of themachine, a video of an installation procedure, a training session, orwhatever information is necessary to assist the service personnel toperform the task at hand.

At step 330, the information requested is displayed through a portabledisplay, e.g., the heads up display 170 or the PDA 160.

In addition to providing a means for service personnel at the riglocation 130 to have access to the computer network 105, thecommunication system 100 may also be used to gather information from therig location 130. For instance, the sensors 180 may be used to obtaintemperature, pressure, flow, torque and turn information, which may beforwarded to the computer 125 at the command center 120 through the PDA160 and the communication network 110. In response, the supportpersonnel at the command center 120 may use the gathered information indetermining a set of instructions for the service personnel at the riglocation 130. In one embodiment, the gathered information may be used togenerate a graph that will assist the support personnel analyze aparticular operation. For instance, if the gathered information isbottomhole pressure of a wellbore, the information may be used togenerate a graph or display that indicates pressure difference betweenthe bottomhole pressure and the formation pressure surrounding thewellbore. This display may then be used to formulate a set ofinstructions to assist the service personnel with the particularoperation.

FIG. 4 illustrates a display 400 that indicates pressure differencebetween bottomhole pressure of a wellbore and formation pressuresurrounding the wellbore in accordance with one or more embodiments ofthe invention. In one embodiment, the display 400 is used in connectionwith underbalanced operations. In another embodiment, the display 400 isthree dimensional.

Bottomhole pressure is generally defined as the pressure at the bottomof a wellbore. Bottomhole pressure may be measured by bottomhole sensorsduring drilling, such as measurements-while-drilling (MWD). Bottomholepressure may also be calculated using various parameters, such as mudweight in pounds per gallon, fluid column, mud column, depth and thelike. Although one or more embodiments of the invention are describedwith reference to bottomhole pressure, other embodiments may contemplateother wellbore pressure, including dynamic friction pressure.

Formation pressure may include pore pressure and fracture pressure.Formation pressure may depend on hydrostatic pressure. Although one ormore embodiments of the invention are described with reference toformation pressure, other embodiments may contemplate other types ofpressure associated with formations surrounding a wellbore.

The display 400 has depth as the vertical axis and pressure as thehorizontal axis. In one embodiment, the depth increases in a downwarddirection, while the pressure increases in a rightward direction. Thedisplay 400 provides an indication of pressure difference between thebottomhole pressure of a wellbore and the formation pressure surroundingthe wellbore from a depth of about 3000 feet and 4000 feet. Morespecifically, the display 400 illustrates a bottomhole pressure curve410 with an indication at each depth as to whether the bottomholepressure is less than, substantially equal to, or greater than theformation pressure. As shown in FIG. 4, each pressure difference isrepresented by a graphical element, such as a bar, circle or bullet.Although various embodiments of the invention are described withreference to a bar, circle or bullet, other embodiments contemplategraphical elements having other geometrical shapes.

As known by persons with ordinary skill in the art, a bottomholepressure that is less than the formation pressure indicates anunderbalanced condition, a bottomhole pressure that is substantiallyequal to the formation pressure indicates a balanced condition and abottomhole pressure that is greater than the formation pressureindicates an overbalanced condition. In one embodiment, a greengraphical element indicates an underbalanced condition, a yellowgraphical element indicates a balanced condition and a red graphicalelement indicates an overbalanced condition. Due to the black and whitecolor limitation in the drawings, the color green is illustrated asblack, the color yellow is illustrated as white and the color red isillustrated with cross hatchings. Although one or more embodiments ofthe invention are described with reference to the color green, white andred, other embodiments contemplate other colors to indicate the variousconditions.

As shown in FIG. 4, the drilling condition at 3100 feet, 3200 feet and3300 feet is indicated by black graphical elements 401, 402 and 403,which correspond to an underbalanced condition. The drilling conditionat 3400 feet, 3500 feet, 3600 feet and 3700 feet is indicated by whitegraphical elements 404, 405, 406 and 407, which correspond to asubstantially balanced condition. The drilling condition at 3800 feet,3900 feet and 4000 feet is indicated by cross hatched graphical elements408, 409 and 411, which correspond to an overbalanced condition.

In one embodiment, the display 400 may also include additional colors toprovide additional granularity for each condition. For instance, anunderbalanced condition with a pressure difference greater than apredetermined pressure may be represented by a dark green graphicalelement, while an underbalanced condition with a pressure differenceless than the predetermined pressure may be represented by a light greengraphical element. Similarly, an overbalanced condition with a pressuredifference greater than a predetermined pressure may be represented by adark red graphical element, while an overbalanced with a pressuredifference less than the predetermined pressure may be represented by apink graphical element. The various colors described herein are used forillustrative purposes only. One or more embodiments of the inventioncontemplate other colors to illustrate the varying pressure differencesbetween bottomhole pressure and formation pressure.

In another embodiment, in addition to having a particular color (e.g.,green), each bar graphical element may be illustrated with a slope. Forinstance, a bar with a slope less than zero indicates an underbalancedcondition, a bar with a slope equal to zero indicates a substantiallybalanced condition and a bar with a slope greater than zero indicates anoverbalanced condition. Further, the steepness of the slope may indicatethe extent of the pressure difference between the bottomhole pressureand the formation pressure, i.e., the greater the pressure difference,the steeper the slope.

FIG. 5 illustrates a flow diagram of a method 500 for displaying a graphindicating the pressure difference between bottomhole pressure of awellbore and formation pressure surrounding the wellbore in accordancewith one or more embodiments of the invention. In one embodiment, method500 is used in connection with an underbalanced operation, e.g.,drilling. At step 510, the bottomhole pressure inside a wellbore for afirst depth is received. In one embodiment, the bottomhole pressure ismeasured during drilling, e.g., measurements-while-drilling (MWD). Inanother embodiment, the bottomhole pressure may also be calculated usingvarious parameters, such as mud weight in pounds per gallon, fluidcolumn, mud column, depth, pump velocity and the like.

At step 520, the bottomhole pressure at the first depth is compared withthe formation pressure at the first depth. The formation pressure may bepreviously measured or calculated using geological or stratographicalinformation acquired during an exploration phase. The formation pressurevalues may be stored in the database 128.

At step 530, a graphical element representing the difference between thebottomhole pressure and the formation pressure at the first depth isillustrated. If the bottomhole pressure at the first depth is less thanthe formation pressure, then the graphical element is illustrated with agreen color, indicating an underbalanced condition. If the bottomholepressure at the first depth is equal to the formation pressure, then thegraphical element is illustrated with a yellow color, indicating abalanced condition. If the bottomhole pressure at the first depth isgreater than the formation pressure, then the graphical element isillustrated with a red color, indicating an overbalanced condition.

In one embodiment, the graphical element that has a shape of a bar mayhave a slope. If the bottomhole pressure is substantially equal to theformation pressure, then the bar has a zero slope, indicating asubstantially balanced condition. If the bottomhole pressure is lessthan the formation pressure, then the bar has a negative slope,indicating an underbalanced condition. If the bottomhole pressure isgreater than the formation pressure, then the bar has a positive slope,indicating an overbalanced condition. Further, the steepness of theslope may vary depending on the amount of the difference between thebottomhole pressure and the formation pressure. Thus, the greater thedifference between the bottomhole pressure and the formation pressure,the steeper the slope will be.

In another embodiment, graphical elements representing varying amountsof pressure difference may be illustrated with different colors. Forinstance, a graphical element representing a pressure difference greaterthan a predetermined amount may have a darker color than a graphicalelement representing a pressure difference less than the predeterminedamount. Details of the various color configuration are described abovewith reference to FIG. 4.

At step 540, a determination is made as to whether processing shouldcontinue at the next depth. If the answer is in the affirmative, thenprocessing returns to step 510, at which the bottomhole pressure at thenext depth is received. In one embodiment, method 500 continues untilthe underbalanced operation, e.g., drilling, of the wellbore iscompleted.

FIG. 6 illustrates a flow diagram of a method 600 for controlling adrilling operation, e.g., underbalanced drilling operation, inaccordance with one or more embodiments of the invention. Method 600 isan example of how the communication system 100 enables a supportpersonnel at the command center to provide his/her expertise to aservice personnel without having to be physically present on the riglocation 130. At step 610, a display indicating the pressure differencebetween bottomhole pressure of a wellbore and formation pressuresurrounding the wellbore at a predetermined depth is generated. Thedisplay is described in more detail in the above paragraphs withreference to FIG. 4. The method for generating such a display isdescribed in more detail in the above paragraphs with reference to FIG.5.

At step 620, the display is reviewed. The display may be reviewed by thesupport personnel at the command center or the service personnel on therig location. The display may be viewed on a display associated with thecomputer 125 or the PDA 160.

At step 630, a trend is identified on the display. In one embodiment,the trend is identified based on the color and the slope of each barrepresenting the pressure difference. As mentioned above, a bar with agreen color and a negative slope may indicate an underbalancedcondition, a bar with a yellow color and a zero slope may indicate abalanced condition, and a bar with a red color and a positive slope mayindicate an overbalanced condition. A trend may be identified within anunderbalanced condition or an overbalanced condition by reviewing theslope of each bar. A decreasing slope within an underbalanced conditionmay indicate a change of condition from underbalanced to balanced oroverbalanced. For instance, as bar 402 transitions to bar 403, the slopeof bar 403 decreases from the slope of bar 402. (See FIG. 4). Thisdecrease in slope may provide a trend that the underbalanced conditionrepresented by bars 401, 402 and 403 is about to change to a balancedcondition or an overbalanced condition. In fact, the bar following bar403 is bar 404, which has a slope of zero, indicating a balancedcondition.

At step 640, a set of instructions is generated based on the identifiedtrend. The set of instructions may be a corrective action that a supportpersonnel at the command center issues to a service personnel on the riglocation. For instance, the set of instructions may include making anumber of adjustments to the drilling equipment to avoid a balanced oroverbalanced condition.

While the foregoing is directed to embodiments of the present invention,other and further embodiments of the invention may be devised withoutdeparting from the basic scope thereof, and the scope thereof isdetermined by the claims that follow.

1. A system for communicating information between a rig location and acomputer network, comprising: the computer network disposed on alocation remote from the rig location; and a computer disposed on therig location, wherein the computer is communicably linked to thecomputer network through a communication link.
 2. The system of claim 1,wherein the computer is a portable computer.
 3. The system of claim 1,wherein the communication link is a communication network.
 4. The systemof claim 3, wherein the communication network is cellular.
 5. The systemof claim 1, wherein the communication link comprises at least one ofwire and cable.
 6. The system of claim 1, wherein the computer comprisesa device for transmitting and receiving audio information on asubstantially real time basis.
 7. The system of claim 1, wherein thecomputer is a handheld computer.
 8. The system of claim 1, wherein thecomputer is a personal digital assistant (“PDA”).
 9. The system of claim2, wherein the computer network comprises a computer on a command centercommunicably linked to the portable computer.
 10. The system of claim 1,further comprising a computer on the rig location, wherein the computeris communicably linked to the computer network.
 11. The system of claim10, wherein the computer controls one or more equipment on the riglocation.
 12. The system of claim 2, further comprising a computer onthe rig location, wherein the computer is communicably linked to theportable computer through a wireless communication network.
 13. Thesystem of claim 1, wherein the computer network comprises a plurality ofcomputers.
 14. The system of claim 1, wherein the computer network iscommunicably linked to a second computer network.
 15. The system ofclaim 1, wherein the computer network comprises the Internet.
 16. Thesystem of claim 1, wherein the rig location is an off shore riglocation.
 17. The system of claim 1, wherein the rig location is an onshore rig location.
 18. The system of claim 1, wherein the rig locationis located off shore and the computer network is located on shore. 19.The system of claim 1, wherein the communication link is a satellitenetwork.
 20. The system of claim 1, wherein the communication link is awireless network.
 21. The system of claim 1, wherein the communicationlink is a fiber optic network.
 22. The system of claim 2, wherein theportable computer is an explosion proof personal digital assistant. 23.The system of claim 2, further comprising a heads up displaycommunicably linked to the portable computer.
 24. The system of claim 2,further comprising a camera communicably linked to the portablecomputer.
 25. The system of claim 2, wherein the portable computercomprises a camera.
 26. The system of claim 2, further comprising acamera communicably linked to the portable computer; and a heads updisplay communicably linked to the portable computer, wherein the cameraand the heads up display are mounted on a hard hat.
 27. The system ofclaim 2, further comprising a camera communicably linked to the portablecomputer; and a heads up display communicably linked to the portablecomputer, wherein the camera and the heads up display are part of videoconference equipment.
 28. The system of claim 2, further comprising asensor communicably linked to the portable computer.
 29. The system ofclaim 28, wherein the sensor is one of a pressure sensor, a temperaturesensor and a flow meter.
 30. The system of claim 2, further comprising asensor communicably linked to the portable computer through a wirelesstransceiver.
 31. A method for communicating information between a riglocation and a computer network disposed on a location remote from therig location, comprising: sending a signal to a computer within thecomputer network to request information; receiving the information fromthe computer within the computer network; and displaying the informationat the rig location.
 32. The method of claim 31, wherein displaying theinformation comprises displaying the information through a portabledisplay.
 33. The method of claim 31, wherein sending the signal to thecomputer comprises sending the signal to a command center to requestinformation from the command center.
 34. The method of claim 31, whereinthe signal comprises at least one of text, audio and video.
 35. Themethod of claim 31, wherein the information comprises a set ofinstructions for a rig operation.
 36. The method of claim 31, whereindisplaying the information comprises displaying at least one of text,still image and video through a heads up display.
 37. The method ofclaim 31, wherein displaying the information comprises displaying atleast one of text, still image and video through a display on a handheldcomputer.
 38. The method of claim 31, wherein displaying the informationcomprises displaying at least one of text, still image and video througha personal digital assistant.
 39. The method of claim 31, whereindisplaying the information comprises broadcasting audio information. 40.The method of claim 31, further comprising capturing an image through acamera; and sending the image to the computer within the computernetwork.
 41. The method of claim 31, further comprising capturing atleast one of temperature, pressure, flow, torque and turn information;and sending the at least one of the temperature, pressure, flow, torqueand turn information to the computer on the command center.
 42. Themethod of claim 41, further comprising receiving a set of instructionsregarding a rig operation in connection with the at least one oftemperature, pressure, flow, torque and turn information.
 43. The methodof claim 31, wherein the rig operation is an offshore rig operation. 44.A method for displaying a graph indicating pressure difference betweenbottomhole pressure of a wellbore and formation pressure surrounding thewellbore, comprising: receiving a bottomhole pressure inside thewellbore at a predetermined depth; comparing the bottomhole pressurewith a formation pressure surrounding the wellbore at the predetermineddepth; and displaying a graphical element indicating a pressuredifference between the bottomhole pressure and the formation pressure.45. The method of claim 44, wherein displaying the graphical elementcomprises displaying a graphical element having a first color torepresent a condition where the bottomhole pressure is less than theformation pressure.
 46. The method of claim 45, wherein the graphicalelement having the first color indicates an underbalanced condition. 47.The method of claim 44, wherein displaying the graphical elementcomprises displaying a graphical element with a negative slope torepresent a condition where the bottomhole pressure is less than theformation pressure.
 48. The method of claim 47, wherein the graphicalelement with the negative slope indicates an underbalanced condition.49. The method of claim 44, wherein displaying the graphical elementcomprises displaying a graphical element with a first color and anegative slope to represent a condition where the bottomhole pressure isless than the formation pressure.
 50. The method of claim 44, whereindisplaying the graphical element comprises displaying a graphicalelement with a second color to represent a condition where thebottomhole pressure is substantially equal to the formation pressure.51. The method of claim 50, wherein the graphical element with thesecond color indicates a substantially balanced condition.
 52. Themethod of claim 44, wherein displaying the graphical element comprisesdisplaying a bar with a zero slope to represent a condition where thebottomhole pressure is substantially equal to the formation pressure.53. The method of claim 52, wherein the graphical element with the zeroslope indicates a substantially balanced condition.
 54. The method ofclaim 44, wherein displaying the graphical element comprises displayinga graphical element with a second color and a slope of zero to representa condition where the bottomhole pressure is substantially equal to theformation pressure.
 55. The method of claim 44, wherein displaying thegraphical element comprises displaying a graphical element with a thirdcolor to represent a condition where the bottomhole pressure is greaterthan the formation pressure.
 56. The method of claim 55, wherein thegraphical element with the third color indicates an overbalancedcondition.
 57. The method of claim 44, wherein displaying the graphicalelement comprises displaying a graphical element with a positive slopeto represent a condition where the bottomhole pressure is greater thanthe formation pressure.
 58. The method of claim 57, wherein thegraphical element with the positive slope indicates an overbalancedcondition.
 59. The method of claim 44, wherein displaying the graphicalelement comprises displaying a graphical element with a third color anda positive slope to represent a condition where the bottomhole pressureis greater than the formation pressure.
 60. The method of claim 44,wherein receiving the bottomhole pressure comprises receiving thebottomhole pressure during at least one of a measurements while drillingoperation and an underbalanced operation.
 61. A display for generating agraphical user interface, comprising: one or more graphical elements,wherein each graphical element indicates a pressure difference between abottomhole pressure of a wellbore at a predetermined depth and aformation pressure surrounding the wellbore; and wherein at least one ofthe graphical elements represents at least one of an underbalancedcondition, a balanced condition and an overbalanced condition.
 62. Thedisplay of claim 61, wherein the at least one of the graphical elementsthat represents the underbalanced condition comprises a first color. 63.The display of claim 61, wherein the at least one of the graphicalelements that represents the underbalanced condition comprises a barhaving a negative slope.
 64. The display of claim 61, wherein the atleast one of the graphical elements that represents the underbalancedcondition comprises a bar having a first color and a negative slope. 65.The display of claim 61, wherein the at least one of the graphicalelements that represents the balanced condition comprises a secondcolor.
 66. The display of claim 61, wherein the at least one of thegraphical elements that represents the balanced condition comprises abar having a zero slope.
 67. The display of claim 61, wherein the atleast one of the graphical elements that represents the balancedcondition comprises a bar having a second color and a zero slope. 68.The display of claim 61, wherein the at least one of the graphicalelements that represents the overbalanced condition comprises a thirdcolor.
 69. The display of claim 61, wherein the at least one of thegraphical elements that represents the overbalanced condition comprisesa bar having a positive slope.
 70. The display of claim 61, wherein theat least one of the graphical elements that represents the overbalancedcondition comprises a bar having a third color and a positive slope. 71.A method for controlling a drilling operation, comprising: reviewing adisplay of one or more graphical elements, wherein each graphicalelement indicates a pressure difference between a bottomhole pressure ofa wellbore at a predetermined depth and a formation pressure surroundingthe wellbore; identifying a trend on the graphical elements; andgenerating a set of instructions based on the trend.
 72. The method ofclaim 71, wherein at least one of the graphical elements represents atleast one of an underbalanced condition, a balanced condition and anoverbalanced condition.
 73. The method of claim 72, wherein the at leastone of the graphical elements that represents the underbalancedcondition comprises a bar having a first color and a negative slope. 74.The method of claim 72, wherein the at least one of the graphicalelements that represents the balanced condition comprises a bar having asecond color and a zero slope.
 75. The method of claim 72, wherein theat least one of the graphical elements that represents the overbalancedcondition comprises a bar having a third color and a positive slope. 76.The method of claim 71, wherein identifying the trend comprisesidentifying the trend based on the color and slope of the graphicalelements.
 77. The method of claim 71, wherein the drilling operation isan underbalanced drilling operation.
 78. The method of claim 71, whereinthe set of instructions comprises one or more actions to adjust adrilling equipment to avoid one of a balanced and an overbalancedcondition.